The Evolution and Application of Formate Brines in
High-Temperature/High-Pressure Operations

Bungert, D.; Maikranz, S.; Sundermann, R.; Downs, J.; Benton, W.; Dick, M.A.

doi:10.2523/59191-ms

Cited by 21 publications

(17 citation statements)

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“…As the weighting agent, the iron ore with the density of 5.0 g/cm 3 along would reduce the whole solid content and viscosity, but would increase the filter loss or even lead to losing all of the fluid (Bungert et al, 2000). Therefore, it is better to use the iron ore mixing the baritite because the baritite, whose structure is fissile, can fill up with the gap of iron ores so as to build up better mud cakes.…”

Section: Weighting Agentsmentioning

confidence: 95%

“…Actually using this kind of drilling fluid can bring about several advantages: (a) ensuring the successful drilling by compressing high pressure gas layer, water layer, or salt aquifer; (b) slowing the velocity of creep (hole shrinkage, collapse, or wellbore instability) by controlling the creep in the gypsum salt bed or brine layer; (c) resisting plastic flow in the soft mudstone; and (d) preventing the wellbore instability, overflow, and blowout. Recently, the drilling fluid with the density of up to 2.0 g/cm 3 is used when drilling high pressure and unstable formations (Julianne and Darby, 1997;Karstad and Bernt, 1998;Thaemlitz et al, 1999;Bungert et al, 2000;Briscoe et al, 2001;Gupta and Santos, 2002;Shahbazi et al, 2006;Stiles and Trigg, 2007). The polymer mud and the oil-based mud are popular, and additives in these systems can prevent the pollution from the gypsum salt, and reduce the shale swelling.…”

Section: Introductionmentioning

confidence: 97%

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Research and Application of High Temperature and Ultrahigh Density Drilling Fluid in Deep Wells

Liu

Chen

Jin

et al. 2013

Petroleum Science and Technology

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Drilling fluid with the high density has been successfully used in many kinds of special formations such as gypsum salt bed, salt aquifer, or compound salt formation. Some problems with this kind of the fluid, however, still have to be considered, for example the high temperature resistance in some complicated deep wells, rheological properties control, and the influence of solid content to rheological properties. The authors introduce, based on the research about some important elements such as rheological properties and the quality of sedimentation stability, a drilling fluid with the high density of 2.45 g/cm 3 that has good rheological properties, excellent qualities of sedimentation stability, low water loss, well antisloughing, and small lubrication coefficient, and which can be perfectly used in the deep slim-hole well with the high pressure salt aquifer. In addition, this drilling fluid system with the density of 2.45 g/cm 3 , no matter in the laboratory test or in the field case (No. 3 well of Jeddah), both performs excellently and controls well the salt crystallization, reducing the rate of the crystallization and preventing sticking, jets blocking, or torque increasing. Finally, with the successful application, this drilling fluid can be regarded as a good example for other deep wells or ultradeep wells with the complicated formation in Fergana Valley, Uzbekistan.

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Section: Weighting Agentsmentioning

confidence: 95%

Section: Introductionmentioning

confidence: 97%

Research and Application of High Temperature and Ultrahigh Density Drilling Fluid in Deep Wells

Liu

Chen

Jin

et al. 2013

Petroleum Science and Technology

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“…Abou-Sayed et al (1996) explained how potassium formate drill-in fluid was used for the first time to drill a horizontal gas well in northern Germany. Bungert et al (2000) showed a limitation and a solution needed when dealing with potassium formate drill-in fluids. The limitation is the reactivity of CO 2 from the gas influx with formate to produce traces of formic acid.…”

Section: Potassium Formate Drill-in Fluidsmentioning

confidence: 99%

Impact of Water-Based Drilling-In Fluids on Solids Invasion and Damage Characteristics

Al-Yami

Nasr‐El‐Din

Al-Shafei

et al. 2009

SPE Production &Amp; Operations

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Drilling the U-formation (shale and sandstone) in Saudi Arabia requires high drilling fluid density (±95 lbm/ft 3 ) to mechanically stabilize the shale and balance the reservoir pressure. Two fluids have been used to drill this formation: KCl/BaSO 4 /CaCO 3 and potassium formate/CaCO 3 drilling fluids. Barite is added in the first fluid with CaCO 3 to reduce the amount of solids needed to formulate the drillin fluid. However, BaSO 4 is insoluble in acids and requires chelating agents (DTPA) to remove it from the formation. Formate drill-in fluids with low solids content can be used, but they are expensive and corrosive at pH values less than 7-8. A third drilling fluid was developed recently by Al-Yami et al. (2007) to overcome some of the problems associated with these two systems.The objectives of this study are to determine solids invasion and damage characteristics for the three fluids. Coreflood tests were conducted using reservoir cores at bottomhole conditions. The cores were then examined by environmental-scanning-electronmicroscope (ESEM) analysis to investigate solids invasion, solids type, and location of damage.The three drilling fluids examined did damage the core plugs either through external filter cake, internal filter cake, or both. The ESEM images showed that the least damage occurred when Mn 3 O 4 water-based drill-in fluid was used. The highest damage was observed when barite/CaCO 3 mud was examined. This was followed by the potassium formate drill-in fluids. Kaolinite booklets were not attacked by the filtrate of the three drill-in fluids examined. The damage that was noted with potassium formate mud resulted from incompatibility of mud filtrate with the formation brine where potassium chloride crystals were noted in the cores.

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“…2,3,4 This property has been used to design high-temperature drilling fluids for operations in other parts of the world, specifically the United Arab Emirates, Central Europe and the North Sea. 5,6 Despite the higher cost of the brine, these fluids in many cases have proven to be more economical overall, as chemical consumption is greatly reduced due to the improvement in thermal stability.…”

Section: Base Fluid Selectionmentioning

confidence: 99%

Reservoir Drilling Fluids-Designing for Challenging Wells in a Remote Location

Knox¹,

Bradshaw²,

Svoboda³

et al. 2005

Proceedings of SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe Belanak A platform is situated in the Natuna Sea region of Indonesia. The reservoir sections are high temperature (315°F BHST), and the openhole sections were planned to be between 3500 and 4500 ft horizontal, some with tortuous well paths required to meet the target. In order to ensure excellent drilling performance and optimum protection of the producing formation, a formate-based, low-solids reservoir drilling fluid was selected -the first time such a system had been used in Indonesia.In this paper, the authors detail the design and successful application of the unique reservoir drill-in fluid in the demanding and remote well.

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The Evolution and Application of Formate Brines in High-Temperature/High-Pressure Operations

Cited by 21 publications

References 0 publications

Research and Application of High Temperature and Ultrahigh Density Drilling Fluid in Deep Wells

Research and Application of High Temperature and Ultrahigh Density Drilling Fluid in Deep Wells

Impact of Water-Based Drilling-In Fluids on Solids Invasion and Damage Characteristics

Reservoir Drilling Fluids-Designing for Challenging Wells in a Remote Location

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